Fluid flow during landing of logging tools in bottom hole assembly

ABSTRACT

Systems and methods for facilitating fluid flow during and after landing of logging tools in a bottom hole assembly are disclosed. A logging tool string is lowered through a drill string and landed in a bottom hole assembly (“BHA”) positioned at the end of the drill string. Drilling fluid is pumped behind the logging tool to assist with downward movement of the tool. As the logging tool string lands in the bottom hole assembly, fluid flowing downward through the BHA below the logging tool string is blocked by the landed logging tool string. The BHA includes a circulation sub positioned above a landing sub. The circulation sub has at least one port through a wall of the circulation sub which allows fluid flow out of the BHA and into the annulus between the wellbore wall and the BHA when the downward flow is blocked.

This disclosure relates to a method and assembly for conveying logging tools in a wellbore and more particularly fluid flow associated with landing of logging tools in a bottom hole assembly.

BACKGROUND

In oil and gas exploration it is useful to obtain diagnostic evaluation logs of geological formations penetrated by a wellbore from a subterranean reservoir. Diagnostic evaluation well logs are generated from data obtained by diagnostic tools (referred to in the industry as logging tools) that are lowered into the wellbore and passed across geologic formations that may contain hydrocarbon substances. Examples of well logs and logging tools include Neutron logs, Gamma Ray logs, Resistivity logs and Acoustic logs. Logging tools are frequently used for log data acquisition in a wellbore by logging in an upward (up hole) direction, such as from a bottom portion of the wellbore to an upper portion of the wellbore. The logging tools, therefore, need first be conveyed to the bottom portion of the wellbore. In many instances, wellbores can be highly deviated, or can include a substantially horizontal section. Such wellbores make downward movement of the logging tools in the wellbore difficult, as gravitational force becomes insufficient to convey the logging tools downhole.

DESCRIPTION OF DRAWINGS

FIGS. 1A to 1E illustrate operations of a logging tool conveying system.

FIGS. 2A to 2K are side views of a logging tool string applicable to the operations illustrated in FIGS. 1A to 1E.

FIGS. 3A to 3C are cross-sectional side views of the logging tool string inside a bottom hole assembly during different operational phases.

FIG. 4 is a detail partial half cross-sectional view of a portion of the logging tool string and the bottom hole assembly illustrating fluid flow ports and flow of fluid during landing of a logging tool string in a bottom hole assembly.

FIG. 5A is a perspective view of a portion of the bottom hole assembly.

FIG. 5B is a cross-section view of the portion of the bottom hole assembly of FIG. 5A.

FIG. 5C is a perspective view of an element of the bottom hole assembly of FIG. 5A.

FIG. 5D is a cross-section view of the element of the bottom hole assembly of FIG. 5C.

FIG. 6A is a perspective view of an alternate implementation of a portion of the bottom hole assembly.

FIG. 6B is a cross-section view of the portion of the bottom hole assembly of FIG. 5A.

FIG. 7 is a detail half cross-section view of a portion of the logging tool string with the running tool released from the logging tool string landed in the bottom hole assembly.

DETAILED DESCRIPTION

The present disclosure relates to systems, assemblies, and methods for facilitating fluid flow during/after landing of logging tools in a bottom hole assembly. In many instances, logging tools carried in a logging tool string are conveyed in a drill string, and landed in a bottom hole assembly at the end of the drill string, in a long deviated well that requires significant pumping pressure for powering the logging tools downwards. The pressure can also be used to monitor the condition, position, and status of the logging tools. The disclosed fluid flow systems, assemblies, and methods can facilitate a continuous measurable pressure for powering and monitoring the logging tools during landing. For example, as the logging tools land, the fluid flow path is blocked by the logging tools. The fluid pressure can rise in response to the narrowing of the fluid flow path. Facilitating fluid flow can put the rising fluid pressure in proper range for powering the logging tools to land and monitoring purposes. Additionally, fluid flow up the annulus between the bottom hole assembly and the well bore wall prevents the bottom hole assembly and the logging tool string from becoming stuck in the wellbore.

In a general implementation, fluid is pumped into the upper proximal end of a drill string bore above a logging tool string to assist movement of the logging tool string downwards by applying fluid pressure on the logging tool string. The fluid flows down the drill string then out circulation ports in the wall of a circulation sub located in the bottom hole assembly. The landing assembly of the logging tool string is landed in the landing sub of the drill pipe. At least a portion of the logging tool string may be disposed below the distal end of the bottom hole assembly.

FIGS. 1A to 1E illustrate operations of a logging tool conveying system 100. The logging tool conveying system 100 includes surface equipment above the ground surface 105 and a well and its related equipment and instruments below the ground surface 105. In general, surface equipment provides power, material, and structural support for the operation of the logging tool conveying system 100. In the embodiment illustrated in FIG. 1A, the surface equipment includes a drilling rig 102 and associated equipment, and a data logging and control truck 115. The rig 102 may include equipment such as a rig pump 122 disposed proximal to the rig 102. The rig 102 can include equipment used when a well is being logged such as a logging tool lubrication assembly 104 and a pack off pump 120. In some implementations, a blowout preventer 103 will be attached to a casing head 106 that is attached to an upper end of a well casing 112. The rig pump 122 provides pressurized drilling fluid to the rig and some of its associated equipment. The data logging and control truck 115 monitors the data logging operation and receives and stores logging data from the logging tools. Below the rig 102 is a wellbore 150 extending from the surface 105 into the earth 110 and passing through a plurality of subterranean geologic formations 107. The wellbore 150 penetrates through the formations 107 and in some implementations forms a deviated path, which may include a substantially horizontal section as illustrated in FIG. 1A. Near the surface 105, part of the wellbore 150 may be reinforced with the casing 112. A drill string 114 can be lowered into the wellbore 150 by progressively adding lengths of drill pipe connected together with tool joints and extending from the rig 102 to a predetermined position in the wellbore 150. A bottom hole assembly 300 may be attached to the lower end of the drill string before lowering the drill string 114 into the wellbore. The drill string 114 can receive a logging tool string 200 that can land onto the bottom hole assembly 300. After landing, the logging tool string 200 can be pulled up and start data logging as it travels upwards.

In a general aspect, referring to FIGS. 3A, 3B, 3C, and 4, the bottom hole assembly 300 includes at least five major sections: the nozzle sub 312, the spacer sub 314, the circulation sub 302, the landing sub 310, and the deployment sub 318. The nozzle sub 312 can function as a connector for attachment to the distal end of the drill string 114, and may be configured such that the logging tool string 200 can be received at and guided through the nozzle sub 312 when the logging tool string 200 enters the bottom hole assembly 300 (FIG. 3A). The spacer sub 314 can define/determine the distance between the nozzle sub 312 and the landing sub 310. The landing sub 310 can include a bore there through and a landing sleeve 340 that receives the logging tool string 200 during landing. In some implementations, the landing sub 310 may include a landing shoulder and a number of control coupling magnets for the landing operation. As illustrated in FIG. 4, one or more ports 313 are located in the sidewall of the circulation sub 302, approximately six inches above the landing shoulder 344 of the landing sub 310 to allow fluid (F) to exit from the inside of the slim bottom hole assembly 300 to the wellbore annulus. The landing shoulder 344 of the landing sleeve 340 does not include downward ports, thereby blocking fluid flow (F) downward inside the bottom hole assembly 300 and around the landing shoulder 344 of the landing sleeve 340. The deployment sub 318 can be the lowermost distal piece of the bottom hole assembly 300 constraining the logging assembly 220, which extends beyond the deployment sub 318 with data logging instruments. In some implementations the deployment sub 318 may be replaced with a modified reamer or hole opener for reaming through a tight spot in the previously drilled wellbore, each of which may be configured to have a longitudinal passage adapted to allow the passage of the logging assembly there through. In other implementations, the deployment sub may not be present and the landing sub may include a lower cutter or reamer that would provide the ability to ream through a tight spot in the preexisting wellbore.

A landing bumper 244 of the tool body is configured to engage the landing shoulder 344 to retain the tool sting 200 and prevent the string from being pumped completely out of the end of the bottom hole assembly 300. When the landing bumper 244 of tool body contacts the landing shoulder 344 of the landing sub 310, the movement of the logging tool string 200 is stopped. Fluid flowing out one or more circulation ports 313 and up the annulus between the bottom hole assembly and the wellbore wall assists in prevention of sticking the bottom hole assembly in the wellbore. The fluid does not flow downward past the engagement of the landing bumper 244 with the landing shoulder 344. The flow ports 312 are spaced a significant distance upstream of the landing shoulder 344 to ensure that the drilling fluid does not flow past the engagement of the landing bumper 244 with the landing shoulder 344. The fluid (F) may be ultimately received at the surface and recirculated down the wellbore.

Various mechanisms can be used to monitor and/or signal the landing, after which a logging sequence can be activated. In some implementations the landing sleeve 340 houses a number of magnets 366 that can be used to activate switches in the logging tool string 200. In the implementation of FIG. 4, a Hall Effect sensor 267 is used as a switch. The Hall Effect sensor 267 is an analog transducer that varies its output voltage in response to a magnetic field. The sensor 267 can be combined with electronic circuitry that allows the device to act in a digital (on/off) mode, i.e., a switch. In this implementation, rare earth magnets located in the landing sub can trigger the sensor 267. In other implementations, reed switches may be actuated by the magnets when the logging tool string 200 is landed. For example, reeds can be deflected to contact each other when the reed switch becomes near the magnets. The magnets can be permanent magnets or electromagnets. Once the Hall Effect sensor 267 or reed switch is activated by being positioned proximal to the magnets in the landing sub 310, an automated self-diagnosis can be initiated in the logging tool string 200 by the diagnostic module to determine when the running tool 202 can be released.

Returning now to FIGS. 1A to 1E, wherein operations of a logging tool conveying system 100 are illustrated. At a starting position as shown in FIG. 1A, the logging tool string 200 is inserted inside the drill string 114 near the upper end of the longitudinal bore of the drill string 114 near the surface 105. The logging tool string 200 may be attached with a cable 111 via a crossover tool 211. As noted above, the bottom hole assembly 300 is disposed at the lower end of the drill string 114 that has been previously lowered into the wellbore 150. The bottom hole assembly 300 may include a landing sub 310 that can engage with the logging tool string 200 once the logging tool string 200 is conveyed to the bottom hole assembly 300. The conveying process is conducted by pumping a fluid from the rig pump 122 into the upper proximal end of the drill string 114 bore above the logging tool string 200 to assist, via fluid pressure on the logging tool string 200, movement of the logging tool string 200 down the bore of the drill string 114.

A landing bumper 244 (FIG. 4) of the tool body can be profiled to engage the landing shoulder 344 (FIG. 4) to retain the tool sting 200 and prevent the string from being pumped completely out of the end of the bottom hole assembly 300. When the landing bumper 244 contacts the landing shoulder 344 of the landing sub 310, the movement of the logging tool string 200 is stopped, but fluid is allowed to flow through or around the logging tool string in order to allow fluid flow at or near the end of the bottom hole assembly 300. The fluid pressure above the logging tool string 200 is monitored constantly, for example, by the data logging control truck, because the fluid pressure can change during the conveying process and exhibit patterns indicating events such as landing the logging tool string 200 at the bottom hole assembly 300. As the logging tool string 200 is pumped (propelled) downwards by the fluid pressure that is pushing behind the logging tool string 200 down the longitudinal bore of the drill string 114, the cable 111 is spooled out at the surface.

In FIG. 1B, the logging tool string 200 is approaching the bottom hole assembly 300. The logging tool string 200 is to be landed in the landing sub 310 disposed in the bottom hole assembly 300 which is connected to the distal lower portion of the drill pipe 114. At least a portion of the logging tool string 200 has logging tools that, when the logging tool string 200 has landed in the bottom hole assembly 300, will be disposed below the distal end of the bottom hole assembly of the drill string 114. In some implementations, the logging tool string 200 includes two portions: a landing assembly 210 and a logging assembly 220. As illustrated in FIG. 1B, the landing assembly 210 is to be engaged with the bottom hole assembly 300 and the logging assembly 220 is to be passed through the bottom hole assembly 300 and disposed below the bottom hole assembly. This enables the logging tools to have direct access to the geologic formations from which log data is to be gathered. Details about the landing assembly 210 and the logging assembly 220 are described in FIGS. 2A to 2E. As the logging tool string 200 approaches the bottom hole assembly 300, the rig pump 122 fluid pressure is observed at the surface 105, for example, at the data logging control truck 115.

A sudden increase of the fluid pressure can indicate that the logging tool string 200 has landed in the landing sub 310 of the bottom hole assembly 300. For example, in FIG. 1C, the logging tool string 200 has landed and engaged with landing sub 310 of the bottom hole assembly 300. The fluid pressure increases because the fluid is not able to circulate past the outside of the upper nozzle 245 when it is seated in the nozzle sub 312. A self-activating diagnostic sequence can be automatically initiated by a diagnostic module located in the logging assembly 220 to determine if the logging assembly 220 is properly functioning. Referring to FIG. 1D, when the proper functioning of the logging tool 220 is confirmed by the downhole diagnostics module, instructions are sent from the downhole diagnostics module to the downhole motor release assembly 213 to release the running tool 202 from the logging tool string 200 and displace the running tool 202 away from the upper end of the logging tool string 200. The running tool 202 includes a crossover tool 211 that connects the cable 111 to the upper nozzle 245 and the spring release assembly 261. A decrease in the pump pressure can then be observed as indicative of release and displacement of the running tool 202 from the logging tool string 200 which again allows fluid to freely circulate past upper nozzle 245. Once the pressure decrease has been observed at the surface, the cable 111 is spooled in by the logging truck 115. A release operation detail view 332 of the release of part of the running tool 202 is shown in FIG. 7. The release operation detail view 332 shows detachment of the spring release assembly 261 from the fishing neck 263. The motor release assembly 213 can include a motorized engagement mechanism that activates the spring release dogs 249 that are securing the running tool 202 to the fishing neck 263. The spring release assembly 261 can include a preloaded spring 258 which forcibly displaces the running tool 202 from the landing nozzle 312.

In FIG. 1E, the cable and the running tool 202 have been completely retrieved and removed from drill string 114. The system 100 is ready for data logging. As discussed above, the logging assembly 220 is disposed below the lower end of the bottom hole assembly 300 and can obtain data from the geologic formations as the logging assembly 220 moves past the formations. The drill string 114 is pulled upward in the wellbore 150 and as the logging tool assembly 220 moves past the geologic formations, data is recorded in a memory logging device that is part of the logging assembly 220 (shown in FIGS. 2A to 2E). The drill string 114 is pulled upward by the rig equipment at rates conducive to the collection of quality log data. This pulling of the drill string 114 from the well continues until the data is gathered for each successive geologic formation of interest. After data has been gathered from the uppermost geologic formations of interest, the data gathering process is completed. The remaining drill pipe and bottom hole assembly containing the logging tool string 200 is pulled from the well to the surface 105. In some implementations, the logging tool string 200 can be removed from the well to the surface 105 by lowering on a cable 111 a fishing tool adapted to grasp the fishing neck 263 while the logging tool string 200 and drill pipe are still in the wellbore. The tool grasps the fishing neck 263 and then the cable is spooled in and the tool and the logging tool string 200 are retrieved. The data contained in the memory module of the logging assembly 220 is downloaded and processed in a computer system at the surface 105. In some implementations, the computer system can be part of the data logging control truck 115. In some implementations, the computer system can be off-site and the data can be transmitted remotely to the off-site computer system for processing. Different implementations are possible. Details of the logging tool string 200 and the bottom hole assembly 300 are described below.

FIGS. 2A to 2K are side views of the logging tool string 200 applicable to the operations illustrated in FIGS. 1A to 1E. The logging tool string 200 includes two major sections: the landing assembly 210, and the logging assembly 220 that can be separated at a shock sub 215. Referring to FIGS. 2A and 2B, the complete section of the landing assembly 210 and a portion of the logging assembly 220 are shown. The landing assembly 210 can include the crossover tool 211, a nozzle 245, a spring release assembly 261, a motorized tool assembly 213, and the shock sub 215. The landing assembly 210 allows the logging tool string 200 to engage with the bottom hole assembly 300 without damage to onboard instruments. A running tool 202 comprises a subset of the landing assembly 210. The running tool 202 includes the crossover tool 211 and the spring release assembly 261. The logging assembly 220 includes various data logging instruments used for data acquisition, for example, a battery sub section 217, a density neutron logging tool 241, a borehole sonic array logging tool 243, a compensated true resistivity tool array 251, among others.

Referring to the landing assembly 210 in FIGS. 1B, 3A and 7, the running tool 202 is securely connected with the cable 111 by crossover tool 211. As the logging tool string 200 is propelled down the bore of the drill string by the fluid pressure, the rate at which the cable 111 is spooled out maintains movement control of the logging tool string 200 at a desired speed. After landing of the logging tool string 200, the running tool 202 can be released (see FIG. 7) by the motorized tool assembly 213. The motorized tool releasable subsection 213 includes an electric motor and a release mechanism including dogs 249 for releasing the running tool section 202 from the fishing neck disposed on the upper portion of the logging assembly 220. The electric motor can be activated by a signal from the diagnostic module in the logging assembly after the diagnostic module has confirmed that the logging assembly is operating properly. The electric motor can actuate the dogs 249 to separate the running tool 202 from the rest of the landing assembly 210.

Referring to the logging assembly 220 in FIG. 2A. The logging assembly 220 and the landing assembly 210 are separated at the shock sub 215. One major functional section behind the shock sub 215 is the battery sub section 217. The battery sub section 217 can include high capacity batteries for logging assembly 220's extended use. For example, in some implementations, the battery sub section 217 can include an array of batteries such as Lithium ion, lead acid batteries, nickel-cadmium batteries, zinc-carbon batteries, zinc chloride batteries, NiMH batteries, or other suitable batteries.

In FIGS. 2D and 2E, the logging assembly 220 further includes the telemetry gamma ray tool 231, a knuckle joint 233 and a decentralizer assembly 235. The telemetry gamma ray tool 231 can record naturally occurring gamma rays in the formations adjacent to the wellbore. This nuclear measurement can indicate the radioactive content of the formations. The knuckle joint 233 can allow angular deviation, although the knuckle joint 233 is placed as shown in FIG. 2D. It is possible that the knuckle joint 233 can be placed at a different location, or a number of more knuckle joints can be placed at other locations of the logging tool string 200. In some implementations, a swivel joint (not shown) may be included below the shock sub assembly 215 to allow rotational movement of the logging tool string 200. The decentralizer assembly 235 can enable the logging tool string 200 to be pressed against the wellbore 150.

In FIGS. 2F to 21, the logging assembly 220 further includes the density neutron logging tool 241 and the borehole sonic array logging tool 243.

In FIGS. 2E and 2K, the logging assembly 220 further includes the compensated true resistivity tool array 251. In other possible configurations, the logging assembly 220 may include other data logging instruments besides those discussed in FIGS. 2A through 2K, or may include a subset of the presented instruments.

FIGS. 3A to 3C are cross-sectional side views of the logging tool string 200 inside the bottom hole assembly 300 during different operation phases. FIG. 3A shows the operation of the logging tool string 200 approaching the bottom hole assembly 300, which can correspond to the scenario shown in FIG. 1B. FIG. 3B shows the operation of the logging tool string 200 landing onto the bottom hole assembly 300, which can correspond to the scenario shown in FIG. 1C. FIG. 3C shows the operation of the logging tool string 200 releasing the running tool 202 after landing onto the bottom hole assembly 300, which can correspond to the scenario shown in FIG. 1D. FIG. 3C further illustrates two detail views: the detail view of the fluid flow portion 334 (FIG. 4) and the release operation detail view 332 (FIG. 7).

Referring to FIG. 3A, the logging tool string 200 is approaching the bottom hole assembly 300 for landing. The shock sub 215 includes a tool body with a landing bumper 244 that has an outer diameter larger than the non-compressible outer diameter of the instruments in the logging assembly 220, so that the logging assembly 220 can go through the landing sub 310 without interfering with the bottom hole assembly 300. A landing bumper 244 outer diameter is larger than the inner diameter of the landing shoulder 344 so that the shock sub 215 can land the logging tool string 200 onto the landing sub 310. For example, at landing the shock sub 215 can impact on the landing shoulder 344 of the landing sub 310 and cease the motion of the logging tool string 200, as illustrated in FIG. 3B.

In FIG. 3C, after the logging tool string 200 is properly landed on the bottom hole assembly 300 and the switch (e.g., hall switch, reed switch etc.) is activated and the running tools 202 can be released from the rest of the logging tool string 200. The activation command requires that the switch remain closed for a pre-determined time period to eliminate false activations from magnetic anomalies found in the drill pipe. The release operation occurs at the motorized tool releasable subsection 213, where the spring release assembly 261 becomes disengaged from the fishing neck 263. The releasing operation can further be illustrated in FIG. 7, where the release operation detail view 332 is shown. Referring to FIG. 7, the spring release assembly 261 is connected to the cable 111 through the crossover tool 211, the nozzle 245 and the extension rod 247. The nozzle 245 can seal with the nozzle sub 312 when the logging tool string 200 is landed to produce a distinct fluid pressure signature. The spring release assembly 261 may include a housing 256, a spring 258, and engaging dogs 249. At release in FIG. 3C, the running tool 202 is moved towards the surface 105 via reeling in the cable 111 at the logging truck 115.

FIG. 4 is a detail partial half cross-sectional view of the fluid flow portion 334 of the logging tool string 200 and the bottom hole assembly 300 illustrating the flow of fluid during landing of the logging tool string 200 in the bottom hole assembly 300. The drill fluid (F) flows down the drill string into the circulation sub 302 and out one or more the ports 313 in the wall of the circulation sub 302.

FIG. 5A is a perspective view of some of the elements of the bottom hole assembly 300. FIG. 5B is a cross-section view of the portion of the bottom hole assembly of FIG. 5A. In a general aspect, as illustrated in FIGS. 3A, 3B, 3C, and 4, in some embodiments the bottom hole assembly 300 may include at least five major sections: the upper nozzle sub 312, the spacer sub 314, the circulation sub 302, the landing sub 310, and the deployment sub 318. FIGS. 5A and 5B illustrate in additional details the upper nozzle sub 312, the circulation sub 302 and the landing sub 310. In particular one or more circulation port(s) 313 are positioned in the circulation sub 302 and one or more auxiliary circulation ports 315 are positioned in the upper nozzle sub 312. As show in the detail in FIGS. 5C and 5D a rupture disc 317 and a retaining ring 319 are positioned in the auxiliary circulation port(s) 315. If one or more of the primary circulation ports 313 become plugged, a rise in the pressure of the circulating fluid (e.g. drilling fluid F—see FIG. 4) will rupture the rupture disc 317 and the fluid will flow out of the auxiliary port(s) 315 and up the annulus in the wellbore. It will be understood that a rupture disc and retaining ring may also be used in one or more of the primary circulation port(s) 313 to increase or decrease the flow of fluid out of the tool and also adjust the resulting pressure of the fluid in the tool due to restriction of the exiting fluid through one or more circulation port(s).

FIG. 6A is a perspective view of an alternate implementation of the bottom hole assembly 300. FIG. 6B is a cross-section view of the alternate embodiment of the bottom hole assembly of FIG. 6A. FIGS. 6A and 6B illustrate the upper nozzle sub 312, a latching sub 380, the circulation sub 302 and the landing sub 310. In particular one or more circulation port(s) 313 are positioned in the circulation sub 302 and one or more auxiliary circulation port(s) 315 are positioned in the upper nozzle sub 312. As show in FIGS. 5C and 5D a rupture disc 317 and a retaining ring 319 are positioned in the auxiliary circulation port(s) 315. If one or more of the primary circulation ports 313 become plugged, the rise in the pressure of the circulating fluid (e.g. drilling fluid F—see FIG. 4) will rupture the rupture disk 317 and the fluid will flow out of the auxiliary port(s) 315 and up the annulus in the wellbore. The latching sub 380 may be configured to receive a portion of the tool string that will latch in the latching assembly 382 of the latching sub and hold the tool string in position.

During operation and referring to both FIG. 1C, FIG. 3B, and FIG. 4, the drill string 114 is run into the wellbore 150 to a predetermined position. The drill string 114 includes a longitudinal bore and the bottom hole assembly 300 that is connected to the lower end of the drill string 114. The bottom hole assembly 300 includes the landing sub 310. The logging tool string 200 is inserted into the proximal upper end of the bore of the drill string 114. The logging tool string 200 can include the landing assembly 210 and one or more logging tools (as shown in FIGS. 2A to 2K). In some implementations, the logging tool string 200 may be inserted into the drill string 114 with tension support from a cable. The cable can be spooled out at the surface for lowering the logging tool string 200 down the longitudinal bore of the drill string 114.

The fluid (F) is pumped into the upper proximal end of the drill string 114 bore above the logging tool string 200 to assist movement of the logging tool sting 200 downwards with force applied onto the logging tool string 200. The fluid force is realized by the pressure differential between the fluid above the logging tool string 200 (e.g., greater pressure) and the fluid below the logging tool string 200 (e.g., lower pressure). As the logging tool string 200 lands, the fluid pressure above the logging tool string 200 will increase because the fluid flowing down and around the tool string and out the end of the bottom hole assembly is stopped due to the closing of a downward flow path around the tool body. The fluid flow path (F) (see FIG. 4) will then be directed out the circulation port(s) 313 and/or out auxiliary circulation port(s) 315 (see FIGS. 5A to 5D and 6A to 6B) to avoid sticking of the BHA in the well bore.

Fluid flowing out the port(s) 313 in the bottom hole assembly and up the annulus between the bottom hole assembly and the wellbore wall assists in prevention of sticking the bottom hole assembly in the wellbore. The fluid (F) may be ultimately received at the surface and re-circulated down the wellbore. During landing, the landing assembly of the logging tool string 200 is landed in the landing sub 310. The landing assembly has a landing bumper 244 to engage the landing shoulder 344 of the landing sleeve 340 of the landing sub 310. At least a portion of the logging tool string 200 (e.g., the various logging tools of FIGS. 2A to 2K) is disposed below the distal end of the bottom hole assembly 300. After the logging tool string 200 has landed, the logging tool string 200 can be pulled upward in the wellbore and record data obtained by one or more of the logging tools about the geologic formations penetrated by the wellbore.

A number of implementations have been described. Nevertheless, it will be understood that various modifications may be made. Further, the method of practicing this disclosure may include fewer steps than those described herein or more steps than those illustrated. In addition, the described steps may be performed in the respective orders discussed or in different orders. Accordingly, other implementations are within the scope of the following claims. 

1. A method, comprising: (a) running a drill string having a longitudinal bore into a wellbore to a predetermined position, said drill string including a bottom hole assembly connected to a lower end of the drill string, said bottom hole assembly including a landing sub and a circulation sub positioned above the landing sub; (b) inserting a logging tool string into an upper end of the bore of the drill string, said logging tool string including a landing assembly and one or more logging tools; (c) pumping a fluid into the upper end of the drill string bore above the logging tool string to assist, via fluid pressure on the logging tool string, movement of the logging tool string down the bore of the drill string; (d) flowing the fluid down the bore of the drill string around the logging tool string as the logging tool string is moving down the bore of the drill string; (e) landing the landing assembly of the logging tool string in the landing sub of the drill pipe, and disposing at least a portion of the tool string including one or more logging tools in the bottom hole assembly; and (f) flowing fluid down the bore of the drill pipe string and out of the drill pipe string through at least one port in the circulation sub and flowing the fluid upward in an annulus between the drill string and a wellbore wall.
 2. The method of claim 1 further comprising: spooling out at the surface a cable attached to the logging tool string as the fluid is pumped behind the tool string and as the tool string is moving down the longitudinal bore of the drill string.
 3. The method of claim 1, wherein landing the logging tool string further comprises disposing at least a portion of the tool string including the one or more logging tools below a distal end of the bottom hole assembly.
 4. The method of claim 1, wherein landing the landing assembly of the logging tool string comprises engaging a landing bumper of the logging tool string with a landing shoulder in the landing sleeve of the landing sub.
 5. The method of claim 1, wherein at least one logging tool is a memory tool operable to store data obtained about at least one geologic formation penetrated by the wellbore.
 6. An assembly for landing of a well tool, the assembly comprising: a bottom hole assembly including a landing sub having a bore there through, and a circulation sub having a bore there through and at least one port through a side wall of the circulation sub, said circulation sub positioned in the bottom hole assembly above the landing sub; and a logging tool string including a landing assembly configured to be received in the landing sub and a logging assembly including at least one logging tool configured to obtain data about at least one geologic formation penetrated by the wellbore.
 7. The assembly of claim 6, wherein said landing sub includes a landing sleeve disposed in the landing sub and a landing shoulder in the landing sleeve; and wherein the landing assembly includes at least one landing bumper configured to be received in the landing shoulder in the landing sleeve of the landing sub.
 8. The assembly of claim 6, wherein the least one logging tool is disposed below a distal end of the bottom hole assembly.
 9. The assembly of claim 8, wherein at least one logging tool is a memory tool operable to store the data obtained about at least one geologic formation penetrated by the wellbore.
 10. The assembly of claim 6, wherein the logging tool string is attachable to a wireline deployable through a drill string.
 11. A logging system for obtaining well log data from a wellbore, the logging system comprising: a drill string disposed in a wellbore, said drill string having a longitudinal bore there through; a bottom hole assembly attached to a lower end of the drill string, said bottom hole assembly including a landing sub having a bore there through, and a circulation sub having at least one circulation port through a sidewall of the circulation sub, said circulation sub disposed in the bottom hole assembly above the landing sub; a tool string including a landing assembly adapted to land in the landing sub, and at least one logging tool; and a surface pump system adapted to pump fluid down the drill string behind the logging tool and out the port in the sidewall of the circulation sub when the landing assembly of the tool string has landed in the landing sub.
 12. The system of claim 11, wherein said landing sub includes a landing sleeve positioned in the landing sub and a landing shoulder disposed in the landing sleeve; and wherein the landing assembly includes at least one landing bumper engageable with the landing shoulder in the landing sleeve of the landing sub.
 13. The system of claim 11, wherein the least one logging tool is disposed below a distal end of the bottom hole assembly.
 14. The system of claim 13, wherein at least one logging tool is a memory tool operable to store data obtained about at least one geologic formation penetrated by the wellbore.
 15. The system of claim 11, wherein the logging tool string is attached to a wireline deployable through the drill string.
 16. The system of claim 11, wherein the surface pump system is operable for pumping fluid down the drill string and out the circulation port in the circulation sub of the bottom hole assembly before and after the landing assembly of the logging tool string has landed in the landing sub.
 17. The method of claim 1 further including flowing the fluid out at least one auxiliary circulation port in an upper nozzle sub positioned in the bottom hole assembly above the circulation sub.
 18. The assembly of claim 6 further including an upper nozzle sub positioned in the bottom hole assembly above the circulation sub, said upper nozzle sub including at least one auxiliary circulating port.
 19. The assembly of claim 18 further including a rupture disk positioned in the circulation port of the circulation sub.
 20. The system of claim 11 further including an upper nozzle sub positioned in the bottom hole assembly above the circulation sub, said upper nozzle sub including at least one auxiliary circulating port.
 21. The system of claim 20 further including a rupture disk positioned in the circulation port of the circulation sub. 